EP1283939B1 - Method for plugging a well with a resin - Google Patents

Method for plugging a well with a resin Download PDF

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Publication number
EP1283939B1
EP1283939B1 EP01953158A EP01953158A EP1283939B1 EP 1283939 B1 EP1283939 B1 EP 1283939B1 EP 01953158 A EP01953158 A EP 01953158A EP 01953158 A EP01953158 A EP 01953158A EP 1283939 B1 EP1283939 B1 EP 1283939B1
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EP
European Patent Office
Prior art keywords
well
resin
cement
rubber
plug
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Legal status (The legal status is an assumption and is not a legal conclusion. Google has not performed a legal analysis and makes no representation as to the accuracy of the status listed.)
Expired - Lifetime
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EP01953158A
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German (de)
English (en)
French (fr)
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EP1283939A1 (en
Inventor
Martin Gerard Rene Bosma
Erik Kerst Cornelissen
Alexander Schwing
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Shell Internationale Research Maatschappij BV
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Shell Internationale Research Maatschappij BV
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Publication of EP1283939A1 publication Critical patent/EP1283939A1/en
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    • E—FIXED CONSTRUCTIONS
    • E21—EARTH OR ROCK DRILLING; MINING
    • E21B—EARTH OR ROCK DRILLING; OBTAINING OIL, GAS, WATER, SOLUBLE OR MELTABLE MATERIALS OR A SLURRY OF MINERALS FROM WELLS
    • E21B36/00—Heating, cooling or insulating arrangements for boreholes or wells, e.g. for use in permafrost zones
    • E21B36/001—Cooling arrangements
    • C—CHEMISTRY; METALLURGY
    • C09—DYES; PAINTS; POLISHES; NATURAL RESINS; ADHESIVES; COMPOSITIONS NOT OTHERWISE PROVIDED FOR; APPLICATIONS OF MATERIALS NOT OTHERWISE PROVIDED FOR
    • C09K—MATERIALS FOR MISCELLANEOUS APPLICATIONS, NOT PROVIDED FOR ELSEWHERE
    • C09K8/00—Compositions for drilling of boreholes or wells; Compositions for treating boreholes or wells, e.g. for completion or for remedial operations
    • C09K8/42—Compositions for cementing, e.g. for cementing casings into boreholes; Compositions for plugging, e.g. for killing wells
    • C09K8/426—Compositions for cementing, e.g. for cementing casings into boreholes; Compositions for plugging, e.g. for killing wells for plugging
    • E—FIXED CONSTRUCTIONS
    • E21—EARTH OR ROCK DRILLING; MINING
    • E21B—EARTH OR ROCK DRILLING; OBTAINING OIL, GAS, WATER, SOLUBLE OR MELTABLE MATERIALS OR A SLURRY OF MINERALS FROM WELLS
    • E21B33/00—Sealing or packing boreholes or wells
    • E21B33/10—Sealing or packing boreholes or wells in the borehole
    • E21B33/13—Methods or devices for cementing, for plugging holes, crevices or the like
    • E21B33/138—Plastering the borehole wall; Injecting into the formation

Definitions

  • This invention relates to a method for carrying out well construction, repair and abandonment operations with a thermosetting resin as seal, plug or connection. More in particular, this invention relates to a method of improving the gas tightness of sealing materials in primary cementing, well repair and plugging operations in oil/gas wells.
  • the main objectives for drilling an oil or gas well are to create a connection to an oil and/or gas reservoir and to install a conduit (called production tubing) between the reservoir and the surface.
  • the outer steel protection of a well is called the casing.
  • the casing requires a gas tight seal between the reservoir and the surface.
  • the annulus (the gap between the casing and the rock/formation) is subjected to a cementing (or grouting) operation.
  • This treatment is normally referred to as Primary Cementing.
  • the main aspects of primary cementing are to isolate flow between different reservoirs, to withstand the external and internal pressures acting upon the well by offering structural reinforcement and to prevent corrosion of the steel casing by chemically aggressive reservoir fluids.
  • a poor cementing job can result in migration of reservoir fluids, even leading to gas migration through micro-annuli in the well which not only reduces the cost-effectiveness of the well but may cause a "blow out” resulting in considerable damage.
  • Repair jobs (“secondary cementing") are possible (in essence forcing more cement into the cracks and micro-annuli). However, they are costly and do not always lead to the desired results.
  • the material should be gas-tight (i.e. withstand at least 2 bar per m), it should have a controllable setting time so that a range of temperatures and well depths (each requiring different conditions) can be coped with, it should be thermally stable up to 250 °C as well as being chemically stable against reservoir fluids for a very long period of time and its rheological properties should be such that pumping through existing oil field equipment can be carried out without too much problems.
  • Rubbers have been proposed in general for use as plugging materials.
  • Rubbers specifically referred to in said US patent specification are natural rubbers, cis-polyisoprene rubber, nitrile-rubber, ethylene-propylene rubber, styrene butadiene rubber, butyl rubber and neoprene rubber.
  • the vulcanization of the rubber involves the cross-linking of the polymer chains which can be accomplished by incorporating one or more cross-linking agents (the most common one being sulphur) in the rubber latex (latex having been defined as the aqueous dispersion or emulsion of the rubber concerned).
  • a method for carrying out well construction, repair and abandonment operations which method involves introducing a resin into a well and curing the same to form a seal, plug or connection, wherein the cured resin is expanded to at least the volume occupied by the resin prior to curing (compensating shrinkage), by cooling the well and curing the resin at a reduced temperature and subsequently allowing the well to reach its static bottom hole temperature.
  • thermosetting resin used in the main claim and throughout the specification refers to "classic” thermosetting resins, as well as ductile, vulcanizable rubbers.
  • Another embodiment of the invention comprises a method for removing a seal, plug or connection made of an expanded resin and used in well construction, repair and abandonment, comprising the steps of a) cooling the well, until the seal, plug or connection has shrunk loose, and b) removing the loose seal, plug or connection.
  • a well preferably an oil or gas well
  • a well is cooled by a significant degree.
  • the degree of cooling is discussed hereinafter.
  • a -preferably liquid- thermosetting resin or vulcanizable rubber is introduced and allowed to react (i.e. cure) until a solid, thermoset resin of nearly the dimensions of the surrounding "mold" is made.
  • the seal, plug or connection will expand more than the well due to the greater thermal expansion coefficients of resins compared to the base materials of the well (e.g., carbon steel casing, primary cement having thermal expansions coefficients in the order of respectively 1.3*10-3 and 1.0*10-3 volume % per degree Centigrade (vol%/°C), whereas that of resins may be e.g., 50-100 x larger).
  • the expansion should at least compensate for shrinkage, ensuring gas tightness of the well, and better even expand beyond such dimension to ensure a very firm bonding with the plug, seal or connector's environment.
  • the well should be cooled by up to 100 °C, for instance up to 50 °C, more suitably from 15 to 40 °C.
  • the candidate well may be cooled by circulation or (preferably) by injection of a cold fluid. This can be achieved via a workstring during a drilling/completion operation, or the completion tubing or coiled tubing for an already completed well.
  • Suitable fluids can be (sea) water, completion brine, hydrocarbons as e.g. diesel, condensate or (to a lesser extent) a drilling fluid.
  • the degree of cooling depends on various parameters. For instance, a practical approach for a well engineer would be to estimate the degree of cooling on the basis of well properties (e.g. static bottom hole temperature, length of the well bore, well geometry and presence of aggressive chemicals), on the basis of the properties of the material used in the well (steel, rock, cement), and on the basis of the properties of the resin (e.g. amount of shrinkage upon curing, difference in thermal expansion coefficient vis-à-vis that of the well materials; rate of curing at the lowered temperature), and on the availability of a cooling medium.
  • well properties e.g. static bottom hole temperature, length of the well bore, well geometry and presence of aggressive chemicals
  • the properties of the material used in the well steel, rock, cement
  • the properties of the resin e.g. amount of shrinkage upon curing, difference in thermal expansion coefficient vis-à-vis that of the well materials; rate of curing at the lowered temperature
  • HPHT High Pressure/High Temperature
  • the extent of cooling may be defined by the product of the temperature difference by which the well is cooled ( ⁇ T in °C) and the difference in thermal expansion coefficient of the resin vis-à-vis that of the well material ( ⁇ X in vol%/°C).
  • this product ⁇ T. ⁇ x is suitably in the range of 0.5 to 10, more suitably in the range of 2.0 to 5, with the range of 3.0 to 3.5 being preferred.
  • Thermosetting resins have been used in wells (oil, gas, water or even waste disposal wells) before. Those having a thermal expansion coefficient significantly greater than 10-3 vol%/°C may in principle be used, as long as shrinkage occurring during curing is compensated for. Also mixtures of resins as well as mixtures with resins and other materials (e.g. Oil Well Cements, whether Ordinary Portland, Blast Furnace Slag or Aluminate) may be used.
  • US patent No. 3,170,516 describes the recompletion of wells, particularly oil and gas wells, wherein the bore of a well pipe is plugged with a liquid mixture of a thermosetting phenolic condensation resin and a catalytic hardener thereof.
  • Epoxy resin compositions that are curable to hard impermeable solids for use in well bores have also been described in US patents Nos. 3,960,801 ; 4,921,047 ; 5,314,023 ; 5,547,027 ; 5,875,844 ; 5,875,845 ; 5,969,006 ; 6,006,834 and 6,012,524 ; in International application WO 94/21886 , and in European patent application No.
  • epoxy resins are base on diglycidyl ethers of bisphenols, Bisphenol-A and Bisphenol-F in particular, and such epoxy resins, if an epoxy resin is used, are preferred.
  • thermosetting resins that have been used in well bore applications, incorporated herein by reference, include ureum, phenol and melamine formaldehyde resins (Derwent abstracts 93-124473/15; 94-016587/03 and 89-032494/05); latex compositions ( US patents Nos. 3,312,296 ; 4,537,918 ; 5,159,980 ; 5,738,463 , and Derwent abstract 98-51909/44); the room temperature vulcanizing silicone and fluorsilicone compounds mentioned before; other resins such as disclosed in US patents Nos.
  • thermosetting resins may be selected on the basis of the thermal expansion coefficient of the resulting thermoset resin, and its reaction (setting) rate.
  • suitable thermosetting resins are those resulting in a thermoset resin preferably having a thermal expansion coefficient that is greater than 0.0015 vol%/°C, more preferably is in the range of 0.02 to 0.20 vol%/°C (as measured by the apparatus disclosed as the third embodiment of this application).
  • the thermoset resin should set sufficiently quickly to benefit from the thermal expansion coefficient when the well temperature increases, e.g. it should react fully in the order of hours compared with the tens of hours required to allow the well to regain its initial (bottom hole static) temperature.
  • suitable resins should be impervious to gas, oil, brines and well-treating chemicals at well operating temperatures and pressures.
  • Particularly suitable resins for use in the methods of the present invention are elastomeric thermoset resins.
  • the vulcanizable rubbers of US patent No. 5,293,938 ; European patent application No. 325,541 and/or international application WO 99/43923 , all incorporated by reference, may be used.
  • thermosetting resins mentioned before and in the section on the background of the invention those of WO 99/43923 are particularly preferred.
  • These RTV silicone rubbers include the condensation products of silanol terminated polymers with a cross-linking agent, as well as the addition/curing (fluor)silicone compositions described therein.
  • RTV Room Temperature Vulcanizing
  • Such two component systems comprise two base chemicals: a hydride functional silicone cross linking agent and a vinyl functional silicone polymer. When these base compounds are brought into contact they will react, presumably via the addition-curing principle as discussed herein before, thereby producing a (fluor)silicone rubber or gel type material.
  • One of the advantages of this curing system is that it does not require an external reagent to initiate reaction (like water, e.g. present in moist air).
  • a further advantage of this curing system is that it does not produce unwanted or damaging by products like alcohols or acetic acid. It is also not limited by diffusion of one of the reactants (e.g. moist air) into the other very viscous component. Therefore, the reaction of the two components will proceed independently of their respective volumes.
  • thermosetting agent is placed in the well, at a desired depth and location (e.g. in the annulus during a primary cementation or as a plug, in a "plug and abandonment” operation). Prior to placement, the well will have been cooled by one of the methods described in the preceding text.
  • thermoset resin e.g., the RTV (fluor)silicone rubbers described in WO 99/43923 expand by some 0.06-0.08 vol%/°C
  • the resin will expand more than the rest of the completion upon re-heating of the well, which 1) will more than compensate for any shrinkage incurred during the setting of the resin (typically some 0.6% upon setting from the liquid to the solid phase) and 2) will improve the chemical and/or physical adhesion process of the resin to the casing wall.
  • the seal may be further improved by enclosing it between a cement pre-flush and after-flush.
  • the cement pre-flush preferably has a higher density than the thermosetting resin which may be achieved by the addition of conventional weighting agents such as barite, hematite, trimagnesium tetroxide, and the like.
  • the cement after-flush preferably has a lower density than the thermosetting resin, e.g. by the addition of extenders e.g. lightweight fillers, hollow microbeads and the like.
  • extenders e.g. lightweight fillers, hollow microbeads and the like.
  • the invention also provides a method for removing a seal made of a thermoset, expanded resin, by cooling the well wherein the seal is used until the seal has sufficiently shrunk to allow its (non-destructive) removal.
  • the specific formulations can for instance be tested in the large-scale gas migration rig which has been described by Bosma et al in "Cementing: How to achieve Zonal Isolation” as presented at the 1997 Offshore Mediterranean Conference, held in Ravenna, Italy and incorporated herein for reference).
  • the equipment comprises in essence a 4 meter high, 17.8 x 12.7 cm (7 x 5 inch) steel annular casing lay-out plus a 50 cm high simulated permeable (3000 mD) reservoir.
  • the equipment can be operated at pressures up to 6 barg and 80 °C.
  • the breakthrough of gas in the evaluation of the dynamic gas sealing ability of a candidate sealing agent e.g.
  • test equipment is in essence a high pressure static gas migration apparatus which can be operated up to 200 barg and 150 °C and comprises a cylinder in which appropriate internals such as plugs or annular casing configurations can be simulated.
  • a cement or other material is allowed to set inside the cylinder at static conditions (i.e. no delta P).
  • the sealant is either present as single phase of a resin, a hybrid (e.g. a mixture of rubber latex compositions or RTV (fluor) silicone rubbers with Oil Well Cements, either Ordinary Portland Cement, Blast Furnace Slag, or Aluminate) or a sandwich of a thermoset rubber with a conventional Oil Well Cement (either Ordinary Portland Cement, Blast Furnace Slag, or Aluminate) on top of it (seen in the direction of the gas flow.
  • a hybrid e.g. a mixture of rubber latex compositions or RTV (fluor) silicone rubbers with Oil Well Cements, either Ordinary Portland Cement, Blast Furnace Slag, or Aluminate
  • Oil Well Cement either Ordinary Portland Cement, Blast Furnace Slag, or Aluminate
  • the resins are placed in this cell at a certain temperature (typically reflecting that of the cooled down well) and downhole pressure and allowed to set, whilst concurrently the cell is heated further to the final Bottom Hole Static Temperature (BHST) of the well (time frame approximately one half to one day). Subsequently, the possible onset of gas leakage is monitored by applying increasing pressure differentials across the plug or annular casing configuration, by decreasing the back pressure at the top of the plug. To calibrate the test equipment default cement formulations can be used.
  • BHST Bottom Hole Static Temperature
  • Fig. 1 a test set-up including a cylindrical pressure vessel 1 provided with opposite end plates 2, 3, and an electrical heater 4 is arranged around the vessel 1.
  • a filter layer 10 is arranged in the pressure vessel 1, between the first resin part 6 and the lower end plate 3.
  • a temperature sensor T is arranged in the pressure vessel 1, between the cement part 8 and the end plate 2.
  • a gas container Gc is in fluid communication with the interior of the pressure vessel 1 at the lower end thereof via a hydraulic line 10, and a back pressure controller Bpc is in fluid communication with the interior of the pressure vessel 1 at the upper end thereof via a hydraulic line 12.
  • Hydraulic line 12 is provided with a flow indicator F, and pressure gauges P are provided at the respective hydraulic lines 10, 12.
  • a controllable valve 14 is provided in a third hydraulic line 16 interconnecting hydraulic lines 10, 12. The test set-up had a diameter of 14 cm and a length of 115 cm.
  • thermosetting resin an RTV silicon rubber (based on DC 3-4230 from the Dow Corning Corporation, Midland, USA, and formulated to have a density of 2.33 g/cc, using silica flour and Microfine Steel (100 Micron e.g. A-100 S ex Höganäs AB, Höganäs, Sweden) was selected, having a setting time of 6 hours at 100 °C.
  • a cement with a density of 1.92 g/cc and a setting time of 5 hours at 100 °C was placed on top of the resin.
  • the simulated seal measured about 0.5 m of resin and 0.5 m of cement.
  • the vessel 1 was closed and pressurized up to 200 barg by means of the gas pressure provided by the gas container GC. Whilst the resin and cement were setting, the set-up was heated within a time frame of half a day from 100 °C to 130 °C, the simulated BHST of the well, to induce expansion of the resin. Next, the pressure drop across the plug was increased in steps of about 10 bar up to 200 bar by successively decreasing the back pressure at the top of the plug by means of the back pressure controller BPC in order to determine the sealing capacity of the plug. The resin/cement sandwich appeared to be fully gas tight up to 200 bar differential pressure, which was the limit of the test.
  • the experimental results show the gas tightness obtained when pre-cooling a simulated oil/gas well by using a standard cement and an addition-curing silicone formulation, in particular when applying such formulations in sandwich type plugs.
  • This analyzer comprises a pressure vessel 20 to hold the sample 22, and a syringe pump 24 to provide the pressure and register the volume change.
  • Pressure vessel 20 is a non magnetic (e.g. INCONEL) (INCONEL is a trademark) High Pressure, High Temperature Pressure vessel, which can accurately mimic realistic oil field conditions.
  • a 'pressurization liquid' that may be either hydrophilic or hydrophobic, depending on the nature of the reacting system to be investigated.
  • Pump 24 is capable of maintaining constant pressure by moving a piston 26.
  • the progress of the setting reaction is monitored on a continuous basis by a frequency (vibration) measurement. It encompasses the determination of the changing Resonance Frequency of a flat spring 28 which is excited by an external Magnetic Field generated by a driving coil 30 (the frequency being continuously swept over a frequency range of some 10-70 Hz).
  • the spring is partly immersed by the resin/cement system to be tested and as such its resonance frequency will increase as the medium (in which it is immersed) will gradually 'harden'.
  • the system can be either volume or pressure controlled, reflecting an isobaric or isochoric operational mode.
  • a continuous frequency sweep (ranging from 10 Hz to 70 Hz) is applied by means of the driving coil 30 onto the flat spring 28 which is fixed at the vessel bottom at one end and which is fully free at the other end.
  • a tiny permanent magnet 32 is mounted at the spring 28 by a magnet holder 33 for excitation of the spring, due its interaction with the continuously changing external magnetic field of the driving coil 30.
  • the input magnetic energy which will result into an oscillation of the spring is fed into the pressure vessel by a highly magnetically conductive pole shoe (not shown).
  • the output signal is then electronically conditioned prior to further processing.
  • the amplitude of the spring and its continuous change of resonance frequency is fully automatically recorded by a Data Acquisition system (hosted by a portable PC).
  • the damping characteristics of the spring system (being related to the viscosity of the resin/cement and the 'Spring Constant' (being related to the elasticity of the liquid or solid) can be determined by an internal algorithm.
  • the analyzer may also be used to determine the volume changes (at isobaric conditions) or alternatively the pressure changes (at isochoric conditions), whilst allowing the candidate cement or resin to set. Both measurements can be performed at either isothermal conditions or for prescribed temperature sweeps over time.
  • volumetric properties (shrinkage or expansion) of resins or oil well cements can be determined, or alternatively their compressibility behaviour (in a time range from the onset of gelling up to far beyond 'final set' of the resin/cement) can be measured.
  • the apparatus is capable to determine the volume change of the materials under investigation as a function of temperature (i.e. the volumetric thermal expansion coefficient, at isobaric conditions), by sweeping the temperature inside the vessel over a certain time period (max delta T of the prototype is about 270 °C, i.e. -20 °C to +250 °C), whilst maintaining the applied pressure. (The maximum operating pressure of the prototype is 1500 barg).
  • volume change features can be de-coupled from the frequency exciter set up (i.e. determination of the resonance-frequency), described earlier, and constructed as a separate apparatus.
  • the analyzer was used to measure the thermal expansion coefficient of the aforementioned RTV Silicone rubber, DC 3-4230 (ex Dow Corning, Midland, USA), being about 0.066 vol% per °C (at 200 barg), and to measure the volume change of the resin during setting (at 100 °C, and 200 barg), being about -0.5 vol%.

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  • Life Sciences & Earth Sciences (AREA)
  • Engineering & Computer Science (AREA)
  • Geology (AREA)
  • General Life Sciences & Earth Sciences (AREA)
  • Mining & Mineral Resources (AREA)
  • Geochemistry & Mineralogy (AREA)
  • Fluid Mechanics (AREA)
  • Environmental & Geological Engineering (AREA)
  • Physics & Mathematics (AREA)
  • Chemical & Material Sciences (AREA)
  • Materials Engineering (AREA)
  • Organic Chemistry (AREA)
  • Sealing Material Composition (AREA)
  • Investigating Strength Of Materials By Application Of Mechanical Stress (AREA)
  • Sampling And Sample Adjustment (AREA)
  • Drilling Tools (AREA)
  • Compositions Of Macromolecular Compounds (AREA)
EP01953158A 2000-05-22 2001-05-21 Method for plugging a well with a resin Expired - Lifetime EP1283939B1 (en)

Priority Applications (1)

Application Number Priority Date Filing Date Title
EP01953158A EP1283939B1 (en) 2000-05-22 2001-05-21 Method for plugging a well with a resin

Applications Claiming Priority (4)

Application Number Priority Date Filing Date Title
EP00304289 2000-05-22
EP00304289 2000-05-22
EP01953158A EP1283939B1 (en) 2000-05-22 2001-05-21 Method for plugging a well with a resin
PCT/EP2001/005854 WO2001090531A1 (en) 2000-05-22 2001-05-21 Method for plugging a well with a resin

Publications (2)

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EP1283939A1 EP1283939A1 (en) 2003-02-19
EP1283939B1 true EP1283939B1 (en) 2007-09-19

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US (1) US6802375B2 (da)
EP (1) EP1283939B1 (da)
AU (2) AU7567201A (da)
BR (1) BR0111032B1 (da)
DK (1) DK1283939T3 (da)
NO (1) NO324297B1 (da)
OA (1) OA12271A (da)
WO (1) WO2001090531A1 (da)

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BR0111032A (pt) 2003-06-17
OA12271A (en) 2006-05-11
US6802375B2 (en) 2004-10-12
DK1283939T3 (da) 2008-01-02
NO324297B1 (no) 2007-09-17
AU7567201A (en) 2001-12-03
BR0111032B1 (pt) 2009-08-11
EP1283939A1 (en) 2003-02-19
NO20025576D0 (no) 2002-11-21
WO2001090531A1 (en) 2001-11-29
NO20025576L (no) 2003-01-20
AU2001275672B2 (en) 2004-11-11

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